Method and system for increasing modified wobbe index control range

ABSTRACT

A system and method for controlling the temperature of a fuel gas. The system and method includes mixing an intermediate pressure feedwater stream from the heat recovery steam generator with a high pressure feedwater stream from the heat recovery steam generator, then using that mixture to heat the fuel gas mixture. The system and method may provide for improved control over the Modified Wobbe Index of the fuel gas, which may allow for greater variation in the composition of the fuel gas.

CROSS-REFERENCE TO RELATED APPLICATION

This application is a divisional of application Ser. No. 11/668,747,filed Jan. 30, 2007, the entire contents of which is incorporated hereinby reference.

BACKGROUND OF THE INVENTION

The present invention may relate to methods and systems for controllingcombustion dynamics in the combustor of a gas turbine and mayparticularly relate to methods for controlling combustion dynamics forvariable fuel gas composition and temperature based on actual calculatedfuel flow to the combustor and heat input to the gas turbine.

Industrial-based turbines are often gas-fired and are typically used atpower plants to drive generators and produce electrical energy. FIG. 1,for example, schematically illustrates a simple cycle, single-shaft,heavy-duty gas turbine, generally designated 10. The gas turbinecomprises an axial flow compressor 12 having a rotor shaft 14. Airenters the inlet of the compressor at 16, is compressed by the axialflow compressor 12 and then is discharged to a combustor 18, where fuelsuch as natural gas is burned to provide high-energy combustion gaseswhich drive the turbine 20. In the turbine 20, the energy of the hotgases is converted into work, some of which is used to drive thecompressor 12 through shaft 14, with the remainder being available foruseful work to drive a load such as a generator 22 by means of rotorshaft 24 for producing electricity. The heat exhaust from the turbine isillustrated at 26 and may be used for other purposes, for example, in acombined cycle system. Additionally, there is illustrated a heatexchanger 28 for heating the fuel inlet to the combustor 18 inaccordance with the present invention.

A current method of heating the fuel gas is to take intermediatepressure (IP) feedwater from intermediate pressure economizer in theheat recovery steam generator (HRSG) and pipe it into the performanceheat exchanger. FIG. 2 schematically illustrates the current method forheating the fuel gas in a simple cycle, single-shaft, heavy-duty gasturbine. Generally, inputs to the turbine include fuel gas 202 and air204, and outputs include electrical energy 206. Fuel gas 202 enters thesystem via conduit 210 and may be split at valve 212 into conduits 214and 216. Via conduit 214 fuel gas enters fuel gas saturator 218, inwhich the fuel gas is moisturized. Other inputs to fuel gas saturator218 include water, which enters via conduit 220. Unused water exits thefuel gas saturator 218 via conduit 222, and moisturized fuel gas exitsthe fuel gas saturator 218 via conduit 224. Via conduits 216 and 224,moisturized and unmoisturized fuel gas are mixed in mixer 226 and fedinto heat exchanger 230, which heats the fuel gas prior to introductioninto turbine 240 via conduit 232.

Air 204, via conduit 234, enters compressor 236, where it is compressedthen is discharged via conduit 238 to turbine 240. Turbine 240 includesa combustor (not shown) where the fuel gas is burned in the presence ofair to generate heat and generates electricity by driving a generator(not shown). Electrical energy 206 exits turbine 240 via carrier 250.Exhaust exits the turbine 240 via conduit 242, which connects to HRSG244. IP feedwater exits HRSG 244 via conduit 246, which introduces theIP feedwater into heat exchanger 230, where it heats the feed gas. Afterheating the feed gas, the IP feedwater exits heat exchanger 230 viaconduit 248. High pressure (HP) feedwater from the intermediate pressureeconomizer in HRSG 244 exits HRSG 244 via conduit 245, which transportsthe HP feedwater so that it can heat a series of drums 247 (e.g., lowpressure, intermediate pressure, and high pressure).

BRIEF DESCRIPTION OF THE INVENTION

In one embodiment, there is a method for controlling a temperature of afuel gas, which may be introduced into a turbine for generatingelectricity. The method includes several steps, including (i) generatingan intermediate pressure feedwater stream and a high pressure feedwaterstream in a heat recovery steam generator using an exhaust fromcombustion involving the fuel gas; (ii) introducing the intermediatepressure feedwater stream into a mixer; (iii) introducing a highpressure feedwater stream into the mixer; (iv) mixing in the mixer theintermediate pressure feedwater stream and the high pressure feedwaterstream; (v) outputting an output stream from the mixer; (vi) introducingthe output stream into a heat exchanger; and (vii) heating the fuel gasin the heat exchanger.

In another embodiment, there is a system for generating electricity. Thesystem includes a heat exchanger for heating fuel gas prior tointroduction into a gas turbine; a gas turbine for receiving the heatedfuel gas and air, wherein the gas turbine generates electrical energy; aheat recovery steam generator for generating intermediate pressurefeedwater and high pressure feedwater; and a mixer for mixingintermediate pressure feedwater generated by the heat recovery steamgenerator and high pressure feedwater, wherein the output stream of themixer is introduced into the heat exchanger.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 schematically illustrates a simple cycle, single-shaft,heavy-duty gas turbine

FIG. 2 schematically illustrates a prior art method for heating the fuelgas in a simple cycle, single-shaft, heavy-duty gas turbine.

FIG. 3 schematically illustrates an embodiment of the present inventionin a simple cycle, single-shaft, heavy-duty gas turbine.

FIG. 4 is a chart illustrating the change in MWI as a function ofnominal fuel temperature in accordance with an embodiment of the presentinvention.

FIG. 5 is a chart illustrating the change in MWI as a function ofnominal fuel temperature using a prior art method.

DETAILED DESCRIPTION OF THE INVENTION

A number of different types of fuel gases may be used for the combustorsof turbines, including, for example, natural gas, LNGs such as propaneand butane, refinery gases, and coal-derived gases. The energy contentof each of these fuels may vary with its source, and of course, theremay be variations in energy content among the various types of fuels.The temperature of the fuel gas supplied to the combustor may also bequite different from system to system. For example, many power plantsgenerating electricity from the output of gas turbines may provide afuel gas heater to provide a constant (or target) fuel gas temperatureto the combustor. Other sites may have a number of boost compressors toelevate the temperature. Thus, different sites may provide fuel gas atdifferent temperatures and pressures. Furthermore, several sites maysource fuel gas from several different vendors, which implies that boththe temperature and composition of the fuel gas may vary.

The standards for setting fuel gas composition and temperature may becharacterized by a parameter called the Modified Wobbe Index (MWI). MWIallows comparison of the volumetric energy content of different fuelgases at different temperatures. Since the gas turbine reacts only toenergy released in the combustors and the fuel flow control process isgenerally a volumetric flow control process, fuels of differentcomposition with relatively close values for MWI can generally beprovided in the same fuel control system.

MWI is defined as:

${{Modified}{\mspace{11mu}\;}{Wobbe}\mspace{14mu}{Index}\mspace{14mu}({MWI})} = {\frac{LHV}{\sqrt{{SG}_{gas} \times T_{gas}}} = \frac{LHV}{\sqrt{\frac{{MW}_{gas}}{28.96} \times T_{gas}}}}$

Where:

LHV=Lower Heating Value of the Gas Fuel (Btu/scf)

SG_(gas)=Specific Gravity of the Gas Fuel relative to Air

MW_(gas)=Molecular Weight of the Gas Fuel

T_(gas)=Temperature of the Gas Fuel (° Rankine)

28.96=Molecular Weight of Dry Air

Allowable variations in MWI are generally less than +/− 5%. Variationsin MWI from the specified value can lead to unacceptable levels ofcombustion dynamics. That is, combustion dynamics may be partially afunction of MWI. Consequently, operation at high levels of variations inthe MWI from a specified value may result in hardware distress or,possibly, a reduction in component life of the combustion system and/ora potential for power generation outage.

As defined above, MWI is a measure of the volume flow containing acertain amount of energy injected to a gas turbine combustor and, thus,may be a measure of the interchangeability of gas fuel in a given systemdesign. Fuels from different sources or fuels composed of differentmixes of gasses may have different energy contents. The fuel system in agas turbine may be generally sized for a nominal volume flow rate havinga certain energy content. Off-design volume flow rate may causecombustion dynamics or other issues. Thus, for a gas turbine to utilizea variety of blended fuels, a method of controlling the MWI may beneeded in some circumstances.

Embodiments of the present methods and apparatuses control MWI bymodifying the temperature of the fuel. The fuel may be heated above thedesign point by some percent. This may expand the acceptable range ofMWI values for fuel that is to be combusted. This also may facilitatetransient periods, such as start up, and decrease the time required forthe system to achieve steady state operation.

In an embodiment, this control is proposed to be incorporated by mixinghigh pressure (HP) feedwater with the IP feedwater from the HRSG. Thismay increase the heat transfer in the performance heat exchangerallowing higher than nominal fuel temperatures. For example, the HPfeedwater may be mixed with IP feedwater up to 1 hour or more aftersystem start up.

At least certain embodiments of the present invention may be used in thefuel gas delivery system. At least certain embodiments of the presentinvention may increase the effective MWI control range allowing theturbine to operate close to the tuned point, even if the fuel supply ischanged and the MWI increases outside the allowable 5% range.

In order to increase the effective MWI control range, the IP feedwaterused to heat the gas in the performance heat exchanger must be broughtto a higher temperature. In other words, the performance heating systemmust be designed with some margin that allows heating above the designpoint. This extra heat capacity may be used to bring the MWI back intospec should it drop below −5% of the nominal MWI set by combustion.

In order to increase the temperature of the IP feedwater, HP feedwaterwill be mixed with the IP feedwater. The pressure of the HP feedwaterwill be reduced such that a mixer can be used without the HP feedwatercausing a flow reversal in the IP feedwater line. The system may alsoincorporate a cold water line that will be allowed to mix with the IPfeedwater in the event that rapid gas cooling is required (MWI is belowthe acceptable range). The three streams may be blended; two at a time,to produce either increased temperature or decreased temperature IPfeedwater. Of course, the IP feedwater may also be used by itselfwithout any mixing at its natural temperature under normal operatingconditions where the MWI is within the system's specification.

In order to support a flexible fuel supply (i.e., changes in thecomposition of fuel gas), Modified Wobbe Index (MWI) controlpossibilities have been explored. Certain embodiments of the presentinvention facilitate the ability to control the gas temperature, andtherefore, MWI, using the performance heat exchanger. While MWI may beadjusted in current designs by reducing fuel temperature, theperformance heat exchanger is already operating at the upper-limit ofits gas heating ability, which permits the MWI to be controlled over arange of −15% to +1% of the nominal MWI as illustrated in FIG. 5.

Projected fuel Lower Heating Values (LHV) may range from nominal by+/−8%. Combustion limits dictate that the MWI should be controlled to+/−5% of the nominal value. Thus, under the current design, the errorcan only be reduced from +8% to 7%. In some embodiments of the presentinvention, the error may be reduced from +8% to +3%, which is within theacceptable range of MWI error.

While the current design will allow the MWI to be adjusted over alimited range, at least certain embodiments of the present inventionwill expand the range over which MWI may be controlled. The upper limitof MWI controllability may be increased further if the pressure of thewater entering the performance heat exchanger is increased. This may bepossible by using the HP feedwater to boost the mixed water pressure,thereby increasing the saturation point of the water and allowing itstemperature to rise without forming steam.

FIG. 3 schematically illustrates an embodiment of the present inventionin a simple cycle, single-shaft, heavy-duty gas turbine. Generally,inputs to the turbine include fuel gas 302 and air 304, and outputsinclude electrical energy 306. Fuel gas 302 enters the system viaconduit 310 and may be split at valve 312 into conduits 314 and 316. Viaconduit 214 fuel gas enters fuel gas saturator 318, in which the fuelgas is moisturized. Other inputs to fuel gas saturator 318 includewater, which enters via conduit 320. Unused water exits the fuel gassaturator 318 via conduit 322, and moisturized fuel gas exits the fuelgas saturator 318 via conduit 324. Via conduits 316 and 324, moisturizedand unmoisturized fuel gas are mixed in mixer 326 and fed via conduit328 into heat exchanger 330, which heats the fuel gas prior tointroduction into turbine 340 via conduit 332. By controlling the inputsinto mixer 326, the moisture content of the fuel gas introduced intoturbine 340 can be controlled.

Air 304, via conduit 334, enters compressor 336, where it is compressedthen is discharged via conduit 338 to turbine 340. Turbine 340 includesa combustor (not shown) where the fuel gas is burned in the presence ofair to generate heat and generates electricity by driving a generator(not shown). Electrical energy 306 exits turbine 340 via carrier 350.

Exhaust exits the turbine 340 via conduit 342, which connects to HRSG344. IP feedwater from the intermediate pressure economizer in HRSG 344exits HRSG 344 via conduit 346, which introduces the IP feedwater intomixer 380. HP feedwater from the intermediate pressure economizer inHRSG 244 exits HRSG 244 via conduit 245, where it is split via valve 392into conduits 249 and 251. Valve 392 controls the relative flowrates ofHP feedwater into conduits 249 and 251. Conduit 249 carries the HPfeedwater so that it can heat a series of drums 247 (e.g., low pressure,intermediate pressure, and high pressure). Via conduit 251 and valve394, some HP feedwater is fed into mixer 380 via conduit 390.

In addition to IP feedwater via conduit 346 and HP feedwater via conduit390, another input to mixer 380 is cold water via conduit 382. Theoutput from mixer 380 is then introduced into heat exchanger 330, whereit heats the feed gas. After heating the feed gas, it exits heatexchanger 330 via conduit 348. The operational parameters (e.g.,temperature, pressure, etc.) of the output of mixer 380 are measured viameasuring device(s) 396. Measuring device sends a control signal tovalves 392 and 384, which control the flowrate of the HP feedwater andcold water. In addition, cold water entering the mixer 380 may bepressurized using pump 386, which is fed by conduit 388 from the coldwater supply. Similarly, the pressure of the HP feedwater may becontrolled via pressure reducing valve 394.

In an embodiment, the IP feedwater has a temperature of 380° F. and amass flowrate of 50,000 pounds per hour (pph). The HP feedwater has atemperature of 600° F. and a mass flowrate of 4100 pph. In thisembodiment, the output of mixer 380 has a temperature of 440° F. Thefuel gas fed to heat exchanger 330 has a temperature of 55° F. Uponexiting heat exchanger 330 via conduit 332, the fuel gas has atemperature of 335° F. In some embodiments, the fuel gas has atemperature of up to 425° F. The above temperatures and mass flowratesare approximate and may vary depending on specific operating conditions.

FIG. 4 provides a chart illustrating the change in MWI as a function ofnominal fuel temperature using a method in accordance with an embodimentof the present invention. FIG. 4 shows that the effective MWI controlrange can be above 5% using a method in accordance with an embodiment ofthe present invention.

In the prior art method using only IP feedwater (generally having atemperature of 380° F.), the effective MWI control range is 1%. FIG. 5provides a chart illustrating the change in MWI as a function of nominalfuel temperature using a prior art method.

Table 1 illustrates certain operating conditions of the heat exchanger(Horizontal with NTIW-Segmental Baffles) in accordance with an exemplaryembodiment. Table 1 shows that the fuel gas may be heated to 410° F.

TABLE 1 Operating conditions of the heat exchanger in accordance with anexemplary embodiment. Process Conditions Cold Shell Hot Tube Flow rate(1000-lb/hr) 75 55 Inlet/Outlet Y (Wt. frac vap.) 1 1 0 0 Inlet/Outlet T(Deg F.) 55 410 440 150 Inlet P/Avg (psia) 490 410

It is noted that as described and claimed, all numbers and numericalranges are approximate.

While the invention has been described in connection with what ispresently considered to be the most practical and preferred embodiment,it is to be understood that the invention is not to be limited to thedisclosed embodiment, but on the contrary, is intended to cover variousmodifications and equivalent arrangements included within the spirit andscope of the appended claims.

What is claimed is:
 1. A method for controlling a temperature of a fuelgas, the method comprising the steps of: generating an intermediatepressure feedwater stream and a high pressure feedwater stream in a heatrecovery steam generator using an exhaust from combustion in a gasturbine involving the fuel gas; introducing the intermediate pressurefeedwater stream into a mixer; introducing the high pressure feedwaterstream into the mixer; mixing in the mixer the intermediate pressurefeedwater stream and the high pressure feedwater stream; outputting anoutput stream from the mixer; introducing the output stream into a heatexchanger; heating the fuel gas in the heat exchanger; and increasing ordecreasing a mass flowrate of the high pressure feedwater stream toachieve a targeted temperature or pressure of the output stream toaffect a Modified Wobbe Index of the fuel gas; and wherein the step ofheating the fuel gas in the heat exchanger controls the Modified WobbeIndex and facilitates correction of +10% error in the Modified WobbeIndex of the fuel gas.
 2. The method of claim 1 further comprising thesteps of: introducing a cold water stream into the mixer and mixing inthe mixer the intermediate pressure feedwater stream, the high pressurefeedwater stream, and the cold water stream.
 3. The method of claim 1further comprising the step of controlling a pressure of the outputstream by adjusting a pressure reducing valve that affects the pressureof the high pressure feedwater stream.
 4. The method of claim 1 furthercomprising the steps of: monitoring a temperature of the output stream;monitoring a pressure of the output stream.
 5. The method of claim 1further comprising the step of outputting the fuel gas from the heatexchanger, wherein the fuel gas has a temperature of at least 335° F.after exiting the heat exchanger.
 6. The method of claim 5, wherein thefuel gas has a temperature of up to 425° F. after exiting the heatexchanger.